Deploying Fluid Tracer Material with a Perforating Gun

ABSTRACT

Apparatus and methods for deploying fluid tracer material with a perforating gun. An example apparatus may include tracer material shaped to facilitate placement within or in association with a perforating gun, wherein detonation of shaped charges of the perforating gun forms perforation tunnels in a subterranean formation and discharges the tracer material from the perforating gun into the perforation tunnels. An example apparatus may include a perforating gun comprising a plurality of shaped charges and containing tracer material, wherein detonation of the shaped charges forms perforation tunnels in the subterranean formation and discharges the tracer material from the perforating gun into the perforation tunnels. An example method may include deploying tracer material into a subterranean formation via a perforating gun.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims priority to and the benefit of U.S. ProvisionalApplication No. 62/886,504, titled “DEPLOYING FLUID TRACERS VIA A SHAPEDCHARGE,” filed Aug. 14, 2019, the entire disclosure of which is herebyincorporated herein by reference.

This application also claims priority to and the benefit of U.S.Provisional Application No. 62/979,240, titled “DEPLYING FLUID TRACERSWITH A PERFORATING GUN,” filed Feb. 20, 2020, the entire disclosure ofwhich is hereby incorporated herein by reference.

BACKGROUND OF THE DISCLOSURE

Wells are generally drilled into a land surface or ocean bed to recovernatural deposits of oil and gas, and other natural resources that aretrapped in subterranean geological formations in the Earth's crust.Testing and evaluation of completed and partially finished wells hasbecome commonplace, such as to increase well production and return oninvestment. Downhole measurements of formation pressure, formationpermeability, and recovery of formation fluid samples may be useful forpredicting economic value, production capacity, and production lifetimeof the subterranean formations.

Completion and stimulation operations of a well, such as perforating andfracturing operations, may also be performed to optimize wellproductivity. Plugging and perforating tools may be utilized to setplugs within a wellbore to isolate portions of the wellbore andsubterranean formations surrounding the wellbore from each other and toperforate the well in preparation for fracturing. Each fracturing stageinterval along the wellbore can be perforated with one or moreperforating tools (i.e., perforating guns) forming one or more clustersof perforation tunnels along the wellbore. Typically, less than 80% ofthe perforation tunnels formed along the wellbore are open and/orfractured as intended and fully contribute to fluid production. Althoughthe oil and gas industry continues to improve perforation and fracturingefficiency, it is significantly less than 100%.

Fluid tracers may be included in fracturing fluid for each fracturingstage interval and transmitted into fractures during each stage offracturing operations. Such fluid tracers may then be detected at thewellsite surface during fluid flow-back and/or production operations toidentify the source of the formation fluid produced at the wellsitesurface. Fluid tracers deployed during each fracturing stage may bedistinguishable from fluid tracers deployed during another fracturingstage. For example, by measuring concentrations and/or quantities ofeach distinguishable fluid tracer within the fluid produced at thesurface, fluid flow (i.e., production) contribution of each fracturingstage interval, and thus effectiveness of perforation and/or fracturingoperations within each fracturing stage interval, can be determined.Such information can be used to evaluate and improve completion plans(e.g., perforation and fracturing plans) to improve hydrocarbonproduction. However, deploying fluid tracers via fracturing fluid duringeach stage of fracturing operations permits fracture analysis at afracturing stage interval level, but not at a fracture cluster levelwithin each fracturing stage interval. Information indicative offracture cluster efficiency can be utilized to further improvecompletion plans and hydrocarbon production.

BRIEF DESCRIPTION OF THE DRAWINGS

The present disclosure is best understood from the following detaileddescription when read with the accompanying figures. It is emphasizedthat, in accordance with the standard practice in the industry, variousfeatures are not drawn to scale. In fact, the dimensions of the variousfeatures may be arbitrarily increased or reduced for clarity ofdiscussion.

FIG. 1 is a schematic view of at least a portion of an exampleimplementation of apparatus according to one or more aspects of thepresent disclosure.

FIG. 2 is a schematic view of at least a portion of an exampleimplementation of apparatus according to one or more aspects of thepresent disclosure.

FIG. 3 is a sectional view of at least a portion of exampleimplementations of apparatus according to one or more aspects of thepresent disclosure.

FIG. 4 is a schematic view of at least a portion of an exampleimplementation of apparatus according to one or more aspects of thepresent disclosure.

FIG. 5 is a sectional view of the apparatus shown in FIG. 4.

FIG. 6 is a schematic view of at least a portion of an exampleimplementation of apparatus according to one or more aspects of thepresent disclosure.

FIG. 7 is a sectional view of the apparatus shown in FIG. 6.

FIG. 8 is a schematic view of at least a portion of an exampleimplementation of apparatus according to one or more aspects of thepresent disclosure.

FIG. 9 is a sectional view of the apparatus shown in FIG. 8.

FIG. 10 is a schematic view of at least a portion of an exampleimplementation of apparatus according to one or more aspects of thepresent disclosure.

FIG. 11 is a sectional view of the apparatus shown in FIG. 10.

FIGS. 12-14 are schematic views of at least a portion of an exampleimplementation of apparatus according to one or more aspects of thepresent disclosure during different stages of tracer material deploymentoperations.

FIGS. 15-17 are schematic views of at least a portion of another exampleimplementation of apparatus according to one or more aspects of thepresent disclosure during different stages of tracer material deploymentoperations.

FIG. 18 is a schematic view of at least a portion of an exampleimplementation of apparatus according to one or more aspects of thepresent disclosure.

FIGS. 19-30 are sectional views of at least a portion of exampleimplementations of apparatus according to one or more aspects of thepresent disclosure.

FIGS. 31-33 are schematic views of at least a portion of an exampleimplementation of apparatus according to one or more aspects of thepresent disclosure during different stages of tracer material deploymentoperations.

FIGS. 34-36 are schematic views of a subterranean formation duringtracer material deployment, fracturing, and flow-back operations,respectively, according to one or more aspects of the presentdisclosure.

DETAILED DESCRIPTION

It is to be understood that the following disclosure provides manydifferent embodiments, or examples, for implementing different featuresof various embodiments. Specific examples of components and arrangementsare described below to simplify the present disclosure. These are, ofcourse, merely examples and are not intended to be limiting. Inaddition, the present disclosure may repeat reference numerals and/orletters in the various examples. This repetition is for simplicity andclarity, and does not in itself dictate a relationship between thevarious embodiments and/or configurations discussed. Moreover, theformation of a first feature over or on a second feature in thedescription that follows, may include embodiments in which the first andsecond features are formed in direct contact, and may also includeembodiments in which additional features may be formed interposing thefirst and second features, such that the first and second features maynot be in direct contact.

Terms, such as upper, upward, above, lower, downward, and/or below areutilized herein to indicate relative positions and/or directions betweenapparatuses, tools, components, parts, portions, members and/or otherelements described herein, as shown in the corresponding figures. Suchterms do not necessarily indicate relative positions and/or directionswhen actually implemented. Such terms, however, may indicate relativepositions and/or directions with respect to a wellbore when an apparatusaccording to one or more aspects of the present disclosure is utilizedor otherwise disposed within the wellbore.

FIG. 1 is a schematic view of at least a portion of an exampleimplementation of a wellsite system 100 according to one or more aspectsof the present disclosure representing an example environment in whichone or more aspects of the present disclosure may be implemented. Thewellsite system 100 is depicted in relation to a wellbore 102 formed byrotary and/or directional drilling and extending from a wellsite surface104 into a subterranean formation 106. The wellsite system 100 may beutilized to facilitate the recovery of oil, gas, and/or other materialsthat are trapped in the formation 106 via the wellbore 102. The wellbore102 comprises a casing 108 secured by cement 109. It is noted thatalthough the wellsite system 100 is depicted as an onshoreimplementation, it is to be understood that the aspects described beloware also generally applicable or readily adaptable to offshoreimplementations.

The wellsite system 100 includes surface equipment 130 located at thewellsite surface 104 and a downhole intervention and/or sensor assembly,referred to as a tool string 110, conveyed within the wellbore 102 alongor through one or more formations 106 via a conveyance line 120 operablycoupled with one or more pieces of the surface equipment 130. Theconveyance line 120 may be or comprise a cable, a wireline, a slickline,a multiline, an e-line, coiled tubing, and/or other conveyance means.Although the tool string 110 is shown suspended in a vertical portion ofthe wellbore 102, it is to be understood that the tool string 110 mayalso or instead be conveyed within non-vertical, horizontal, andotherwise deviated portions of the wellbore 102.

The conveyance line 120 may be operably connected with a conveyancedevice 140 operable to apply adjustable downward and/or upward forces tothe tool string 110 via the conveyance line 120 to convey the toolstring 110 within the wellbore 102. The conveyance device 140 may be,comprise, or form at least a portion of a sheave or pulley, a winch, adrawworks, an injector head, and/or another device coupled to the toolstring 110 via the conveyance line 120. The conveyance device 140 may besupported above the wellbore 102 via a mast, a derrick, a crane, and/oranother support structure 142. The surface equipment 130 may furthercomprise a reel or drum 146 configured to store thereon a wound lengthof the conveyance line 120, which may be selectively wound and unwoundby the conveyance device 140 to selectively convey the tool string 110into, within, and out of the wellbore 102.

Instead of or in addition to the conveyance device 140, the surfaceequipment 130 may comprise a winch conveyance device 144 comprising oroperably connected with the drum 146 and operable to selectively conveythe tool string 110 within the wellbore 102. The drum 146 may be rotatedby a rotary actuator 148 (e.g., an electric motor) to selectively unwindand wind the conveyance line 120, thereby applying an adjustable tensileforce to the tool string 110 to selectively convey the tool string 110into, within, and out of the wellbore 102.

The conveyance line 120 may comprise metal tubing, support wires, and/orcables configured to support the weight of the downhole tool string 110.The conveyance line 120 may also comprise one or more insulatedelectrical and/or optical conductors 122 operable to transmit electricalenergy (i.e., electrical power) and electrical and/or optical signals(i.e., information or data) between the tool string 110 and one or morecomponents of the surface equipment 130, such as a power and controlsystem 150. The conveyance line 120 may comprise and/or be operable inconjunction with means for communication between the tool string 110,the conveyance device 140, the winch conveyance device 144, and/or oneor more other portions of the surface equipment 130, including the powerand control system 150.

The wellbore 102 may be capped by a plurality (e.g., a stack) of fluidcontrol devices 132, such as fluid control valves, spools, and fittingsindividually and/or collectively operable to direct and control the flowof fluid out of the wellbore 102. The fluid control devices 132 may alsoor instead comprise a blowout preventer (BOP) stack operable to preventthe flow of fluid out of the wellbore 102. The fluid control devices 132may be mounted on top of a wellhead 134.

A sealing and alignment assembly 136 may be mounted on the fluid controldevices 132 to seal the conveyance line 120 during deployment,conveyance, intervention, and other wellsite operations. The sealing andalignment assembly 136 may comprise a lock chamber (e.g., a lubricator,an airlock, a riser, etc.) mounted on the fluid control devices 132, astuffing box operable to seal around the conveyance line 120 at top ofthe lock chamber, and return pulleys operable to guide the conveyanceline 120 between the stuffing box and the drum 146, although suchdetails are not shown in FIG. 1. The stuffing box may be operable toseal around an outer surface of the conveyance line 120, such as viaannular packings applied around the surface of the conveyance line 120and/or by injecting a fluid between the outer surfaces of the conveyanceline 120 and an inner wall of the stuffing box. The tool string 110 maybe deployed into or retrieved from the wellbore 102 via the conveyancedevice 140 and/or winch conveyance device 144 through the sealing andalignment assembly 136, the fluid control devices 132, and/or thewellhead 134.

The power and control system 150 (e.g., a control center) may beutilized to monitor and control various portions of the wellsite system100 by a human operator (e.g., wellsite personnel). The power andcontrol system 150 may be located at the wellsite surface 104 or on astructure located at the wellsite surface 104. However, the power andcontrol system 150 may instead be located remote from the wellsitesurface 104. The power and control system 150 may include a source ofelectrical power 152, a memory device 154, and a surface controller 156(e.g., a processing device or computer) operable to receive and processsignals or information from the tool string 110 and/or commands from thehuman operator. The power and control system 150 may be communicativelyconnected with various equipment of the wellsite system 100, such as maypermit the surface controller 156 to monitor operations of one or moreportions of the wellsite system 100 and/or to provide control of one ormore portions of the wellsite system 100, including the tool string 110,the conveyance device 140, and/or the winch conveyance device 144. Thesurface controller 156 may include input devices for receiving commandsfrom the human operator and output devices for displaying information tothe human operator. The surface controller 156 may store executableprograms and/or instructions, including for implementing one or moreaspects of methods, processes, and operations described herein.

The tool string 110 may comprise a cable head 112 (i.e., a logging head,a cable termination sub, etc.) operable to physically and/orelectrically connect the conveyance line 120 with the tool string 110.The cable head 112 may thus permit the tool string 110 to be suspendedand conveyed within the wellbore 102 via the conveyance line 120.

The tool string 110 may further comprise one or more downhole tools 114(e.g., devices, modules, subs, etc.) operable to perform downholeoperations. The tools 114 of the tool string 110 may comprise atelemetry tool, such as may facilitate communication between the toolstring 110 and the surface controller 156. The tools 114 may comprise adownhole controller communicatively connected with the surfacecontroller 156 via the conductor 122 and with other portions of the toolstring 110. The downhole controller may be operable to store and/orcommunicate to the tool string control system 150 signals or informationgenerated by one or more sensors or instruments of the tool string 110.The downhole controller may be operable to control one or more portionsof the tool string 110. For example, the downhole controller may beoperable to receive, store, and/or process control commands from thetool string control system 150 for controlling one or more portions ofthe tool string 110. The tools 114 may further comprise one or moreinclination and/or directional sensors, such as one or moreaccelerometers, magnetometers, gyroscopic sensors (e.g.,micro-electro-mechanical system (MEMS) gyros), and/or other sensors fordetermining the orientation and/or direction of the tool string 110within the wellbore 102. The tools 114 may also or instead comprise adepth correlation tool, such as a casing collar locator (CCL) fordetecting ends of casing collars by sensing a magnetic irregularitycaused by the relatively high mass of an end of a collar of the casing108. The depth correlation tool may also or instead be or comprise agamma ray (GR) tool.

The tool string 110 comprises one or more perforating tools 116 (i.e.,perforating guns) operable to perforate or form perforations (e.g.,holes) though the casing 108, the cement 109, and a portion of theformation 106 surrounding the wellbore 102 to prepare the well forstimulation (e.g., hydraulic fracturing) and production. Eachperforating tool 116 may comprise a plurality (e.g., a set or cluster)of perforating devices 117 (e.g., shaped explosive charges). Eachperforating device 117 may be operable to perforate the casing 108, thecement 109, and the formation 106 upon detonation. Each perforating tool116 may thus be operable to form a plurality 111 (e.g., a set orcluster) of perforation tunnels 113 extending through the casing 108 andthe cement 109 and into the formation 106. The tool string 110 may alsocomprise one or more plugs 118 and plug setting tools 119 for settingthe plugs 118 at intended (i.e., predetermined) positions within thewellbore 102, such as to isolate or seal portions (e.g., the fracturingstage intervals 103, 105, 107) of the wellbore 102 between successivestages of fracturing operations.

The power and control system 150 (e.g., surface controller 156) may becommunicatively and/or electrically connected with the tool string 110via the conductor 122 extending between the power and control system 150and the tool string 110. However, the tool string 110 may also orinstead be communicatively connected with the power and control system150 by other means, such as capacitive or inductive coupling. Theconductor 122 may extend through or along at least a portion of the toolstring 110, such as to communicatively and/or electrically connect oneor more portions of the tool string 110 with the power and controlsystem 150. The electrical conductor 122 extending through the toolstring 110 may also facilitate electrical communication between two ormore portions of the tool string 110. One or more of the cable head 112,the downhole tools 114, the perforating tools 116, and/or the plugsetting tool 119 may comprise corresponding electrical conductors,connectors, and/or interfaces forming a portion of the conductor 122extending through the tool string 110. The conductor 122 may extendthrough the conveyance line 120 and externally from the conveyance line120 at the wellsite surface 104 via a rotatable joint or coupling (e.g.,a collector) (not shown) carried by the drum 146.

During plugging and perforating (“plug and perf”) operations, a plug 118may be set (i.e., installed) within the wellbore 102 by the plug settingtool 119 to seal a previously fractured (lower) fracturing stageinterval 103 of the wellbore 102 from a subsequent (upper) fracturingstage interval 105 of the wellbore 102. The plug 118 may be permanent orretrievable, facilitating the fracturing stage interval 103 to bepermanently or temporarily isolated or sealed from the fracturing stageinterval 105. After the plug 118 is set within the wellbore 102, thetool string 110 may be conveyed upward to an intended depth and one ormore of the perforating tools 116 may be operated to form an intendedquantity of clusters 111 of perforation tunnels 113 through the casing108 and the cement 109 and into the formation 106 within the fracturingstage interval 105. After the wellbore 102 is perforated at one or moredepths within the fracturing stage interval 105, the tool string 110 maybe retrieved from the wellbore 102 and the fracturing stage interval 105may be hydraulically fractured, such as via pressure-pumping operations.

After the fracturing stage interval 105 is fractured, the tool string110 may be deployed within the wellbore 102 and conveyed to an intendeddepth. The plug setting tool 119 may then set another plug 118 withinthe wellbore 102 to fluidly seal the previously fractured (now lower)fracturing stage interval 105 from a subsequent (upper) fracturing stageinterval 107. One or more other perforating tools 116 may be operated toperforate the casing 108, the cement 109, and the formation 106 at oneor more depths within the fracturing stage interval 107. After anintended quantity of clusters 111 of perforation tunnels 113 are formedalong the wellbore 102 within the fracturing stage interval 107, thetool string 110 may be retrieved from the wellbore 102 and thefracturing stage interval 107 may be fractured. Such actions may berepeated for each subsequent fracturing stage interval until the entirewellbore 102 is prepared for production.

FIG. 2 is a schematic side view of at least a portion of an exampleimplementation of a perforating tool 200 (i.e., a perforating gun)according to one or more aspects of the present disclosure. Theperforating tool 200 may be an example implementation of, and/orcomprise one or more features of, the perforating tools 116 describedabove and shown in FIG. 1. Accordingly, the following description refersto FIGS. 1 and 2, collectively.

The perforating tool 200 comprises a plurality of perforating devices210 (e.g., shaped charges, shaped explosives, perforating charges,etc.), each comprising a liner 214, an explosive material 212 on oneside of the liner 214, and a case 215 on one side of the explosivematerial 212. After the perforating tool 200 is conveyed to an intendeddepth within the wellbore 102, the explosive material 212 of eachperforating device 210 can be detonated to propel a corresponding liner214 at a high speed and pressure into a sidewall of the wellbore 102 toperforate or otherwise create a perforation tunnel 113 through thecasing 108 and the cement 109 and into the formation 106 surrounding thewellbore 102. Although the perforating tool 200 is shown comprisingsixteen perforating devices 210 (four columns of perforating devices 210distributed at 90 degrees apart) and thus operable to create a cluster111 of sixteen perforations 113, it is to be understood that theperforating tool 200 can include other quantities of perforating devices210.

Each explosive material 212 of the perforating devices 210 may bedetonated by a detonating cord 220 connected with or otherwise disposedin association with each perforating device 210 of the perforating tool200. An electrical detonator 218 may be connected with the detonatingcord 220 and operable to detonate the detonating cord 218 to detonatethe explosive material 212 of each perforating device 210. The detonator218 may be connected to an electrical conductor 222, which may extendthough the perforating tool 200 between opposing upper and lower ends ofthe perforating tool 200. The conductor 222 may be connected with orform a portion of the conductor 122 extending through the tool string110 and the conveyance line 120 to the surface equipment 130. Thedetonator 218 may also or instead be communicatively connected with adetonator switch (e.g., an addressable switch, a pressure switch, etc.)(not shown) located within the tool string 110. The detonator switch mayfacilitate selective detonation, from the wellsite surface 104, of theexplosive material 212 of the perforating devices 210 of one or moreperforating tools 200 coupled along the tool string 110.

The perforating devices 210 may be held in relative position and in anintended direction by a support tube 224 (i.e., a charge tube). Forexample, the perforating devices 210 may be distributed longitudinallyand circumferentially along the support tube 224 and directed radiallyoutward from the support tube 224. Each perforating device 210 may bedisposed partially or entirely within a corresponding cavity or openingextending radially within or through the support tube 224. The supporttube 224 may be disposed within an outer housing 226 (i.e., a carriertube) of the perforating tool 200. The outer housing 226 may fluidlyisolate internal portions (e.g., each perforating device 210) of theperforating tool 200 from wellbore fluid when the perforating tool 200is conveyed within the wellbore 102.

The perforating tool 200 may comprise an upper (i.e., uphole) connector230 operable to mechanically and electrically connect the perforatingtool 200 with an upper portion of the tool string 110, such as adownhole tool 114 or another perforating tool 200. The perforating tool200 may further comprise a lower (i.e., downhole) connector 232 operableto mechanically and electrically connect the perforating tool 200 with alower portion of the tool string 110, such as a plug setting tool 119 oranother perforating tool 200.

FIG. 3 is a sectional side view of at least a portion of an exampleimplementation of a perforating device 300 (i.e., a shaped charge,shaped explosive, a perforating charge, etc.) according to one or moreaspects of the present disclosure. The perforating device 300 may be orcomprise an example implementation of, and/or comprise one or morefeatures of, the perforating devices 117, 210 described above and shownin FIGS. 1 and 2, respectively. A plurality of perforating devices 300may be installed or otherwise utilized in association with a perforatingtool, such as the perforating tool 116, 200 described above and shown inFIGS. 1 and 2, respectively. Accordingly, the following descriptionrefers to FIGS. 1-3, collectively.

The perforating device 300 may comprise a case 310 (i.e., a housing), amain explosive material 312 (i.e., a main explosive load, a secondaryexplosive, etc.) disposed within the case 310, and a liner 314 partiallysurrounded by the main explosive material 312. The liner 314 may have agenerally conical shape, having an outer surface in contact with themain explosive material 312 and an inner surface defining aconical-shaped hollow (e.g., air-filled) cavity 320 (i.e., a stand-offspace). The liner 314 may be or comprise a metal, such as copper,aluminum, lead, and/or tin, among other examples. The liner 314 may beor comprise a powdered metal, such as a metal matrix composite, shaped(e.g., pressed) into an intended form. The cavity 320 may define a frontface of the perforating device 300. A primer explosive material 316(i.e., primer load) may be disposed at the base (or bottom) of the case310 in contact with the main explosive material 312 and adjacent anopening or hole 318 through the case 310. A detonating cord 317 mayextend along the case 310 adjacent to or over the hole 318. Thedetonating cord 317 may be connected to the case 310 via a guide orholder (not shown) integrally formed with or otherwise connected withthe case 310. Upon being detonated by a detonator 218, the detonatingcord 317 detonates the primer explosive material 316, which, in turn,detonates the main explosive material 312. The main explosive material312 may be or comprise, for example, RDX, HMX, or HNS, and a bindingagent (i.e., binder), such as wax or a polymer. The primer explosivematerial 316 may be or comprise, for example, RDX, HMX, or HNS, butwithout a binding agent. Although the main explosive material 312 of theperforating device 300 may be detonated by the detonating cord 317 andthe primer explosive material 316, it is to be understood that the mainexplosive material 312 may be detonated by other means, such as anelectric detonator (i.e., a blasting cap) (not shown) disposed at thebase of the case 310 and electrically connected with the conductor 222or a detonator switch.

The present disclosure is further directed to systems and methods (e.g.,steps, operations, processes, etc.) for deploying tracer material into asubterranean formation 106 and then monitoring the tracer materialcarried by the formation fluid to the wellsite surface 104 to trace thesource of the formation fluid. The tracer material may be may bedisposed within or otherwise as part of the perforating tool 200. Forexample, the tracer material may be installed or otherwise disposed inassociation with the perforating devices 210. The tracer material mayalso or instead be disposed within the support tube 224. The tracermaterial may also or instead be disposed within an annular space 228between the support tube 224 and the outer housing 226. Duringperforation operations, high pressure gas is released upon detonationand explosion of the explosive material 212 of the perforating devices210, increasing internal pressure within the perforating tool 200. Thehigh-pressure gas then escapes from the perforating tool 200 at highspeed via holes formed (e.g., cut) by the high-speed liner and the forceof the exploding explosive material 212. The escaping, high-pressure gasmay break up and drawl, propel, discharge, or otherwise force the tracermaterial out of the perforating tool 200 and into the perforationtunnels 113 in the formation 106 formed by the high-speed liners 214,thereby deploying the tracer material into the formation 106.

After the tracer material is deployed into the formation 106,concentrations or amounts of the tracer material being carried orflowing back to the wellsite surface 104 during flow back and/orproduction may be detected at the wellsite surface 104 to identify thesource of the formation fluid reaching the wellsite surface 104. Thetracer material associated with different perforating devices 210 and/ordifferent perforating tools 200 may be different or otherwisedistinguishable (i.e., comprising different detectable signatures orcharacteristics) from each other, thereby permitting identification ofthe source of formation fluid flowing to the wellsite surface 104.Accordingly, the tracer material may be used to monitor or identifycontributions of formation fluids (e.g., hydrocarbons) flowing fromdifferent portions (e.g., fracturing stage intervals and/or clusters ofperforation tunnels) of the wellbore 102 and the formation 106 to thewellsite surface 104. The tracer material may be or comprise, forexample, radioactive tracers, chemical tracers, deoxyribonucleic acid(DNA) tracers, and/or other fluid tracers. Each type of tracer materialmay be associated with a corresponding means of being detected in thefluid at the wellsite surface 104.

FIG. 4 is a schematic side view of at least a portion of an exampleimplementation of a perforating tool 410 (i.e., a perforating gun)according to one or more aspects of the present disclosure. FIG. 5 is asectional axial view of the perforating tool 410 shown in FIG. 4. Theperforating tool 410 may be an example implementation of, and/orcomprise one or more features of, the perforating tool 200 describedabove and shown in FIG. 2, including where indicated by the samereference numerals. The following description refers to FIGS. 1, 2, 4,and 5, collectively.

The perforating tool 410 may contain tracer material 412 in an annularspace 414 between the support tube 224 and the outer housing 226 infront of the perforating devices 210 such that, upon detonation of theperforating devices 210, a high-speed and high-pressure jet of linerparticles and gas caused by detonation of the perforating devices 210draws, propels, discharges, or otherwise forces the tracer material 412out of the perforating tool 420 and into the perforation tunnels 113formed by the perforating devices 210 in the formation 106. The tracermaterial 412 may be inserted or otherwise disposed into the annularspace 414 (such as via a radial opening in a sidewall of the outerhousing 226, as indicated by arrow 416, or via an axial opening at anend of the outer housing 226, as indicated by arrow 418) after thesupport tube 224 is inserted into the outer housing 226 and before theouter housing 226 is enclosed by connection of the upper connector 230with the outer housing 226.

The tracer material 412 may be or comprise tracer material particles(e.g., powder, pellets, etc.) that can be poured, dispensed, orotherwise disposed into the annular space 414. The tracer material 412may instead be formed or otherwise shaped into one or more solid unitsor members to facilitate placement within the annular space 414. Forexample, the tracer material 412 may be formed or otherwise shaped intoone or more ring-shaped or annular-shaped members to permit placementwithin the annular space 414 around the support tube 224. The tracermaterial 412 may instead be formed or otherwise shaped into a pluralityof ring or annular segments to permit placement within the annular space414 to collectively extend around the support tube 224. Each unit oftracer material 412 may be shaped by compressing or pressing the tracermaterial particles within a mold having the intended shape of the tracermaterial 412. The tracer material 412 may also or instead be shaped bymixing tracer material particles with a fluid binder to form a tracermaterial slurry, which may be poured into a mold having the intendedshape of the tracer material 412 and permitted to solidify. The tracermaterial 412 may also or instead be shaped by melting solid tracermaterial (e.g., tracer material particles), pouring the molten tracermaterial into a mold having the intended shape of the tracer material412, and cooling molten tracer material within the mold.

FIG. 6 is a schematic side view of at least a portion of an exampleimplementation of a perforating tool 420 (i.e., a perforating gun)according to one or more aspects of the present disclosure. FIG. 7 is asectional axial view of the perforating tool 420 shown in FIG. 6. Theperforating tool 420 may be an example implementation of, and/orcomprise one or more features of, the perforating tool 200 describedabove and shown in FIG. 2, including where indicated by the samereference numerals. The following description refers to FIGS. 1, 2, 6,and 7, collectively.

The perforating tool 420 may contain tracer material 422 within aninternal space 424 of the support tube 224 adjacent the perforatingdevices 210 such that, upon detonation of the perforating devices 210, ahigh-speed and high-pressure jet of liner particles and gas caused bydetonation of the perforating devices 210 draws, propels, discharges, orotherwise forces the tracer material 422 out of the perforating tool 420and into the perforation tunnels 113 formed by the perforating devices210 in the formation 106. The tracer material 422 may be or comprisetracer material particles (e.g., powder, pellets, etc.) that can bepoured, dispensed, or otherwise disposed into the internal space 424,such that the tracer material 422 fills the internal space 424 aroundand between the perforating devices 210. The tracer material 422 may beinserted or otherwise disposed into the internal space 424 (such as viaa radial opening in a sidewall of the support tube 224, as indicated byarrow 426, or via an axial opening at an end of the support tube 224, asindicated by arrow 428) before the support tube 224 is inserted into theouter housing 226 or before the outer housing 226 is enclosed viaconnection of the upper connector 230 with the outer housing 226.

FIG. 8 is a schematic side view of at least a portion of an exampleimplementation of a perforating tool 430 (i.e., a perforating gun)according to one or more aspects of the present disclosure. FIG. 9 is asectional axial view of the perforating tool 430 shown in FIG. 8. Theperforating tool 430 may be an example implementation of, and/orcomprise one or more features of, the perforating tool 200 describedabove and shown in FIG. 2, including where indicated by the samereference numerals. The following description refers to FIGS. 1, 2, 8,and 9, collectively.

The perforating tool 430 may contain tracer material 432 within aninternal space 434 of the support tube 224 between and adjacent theperforating devices 210 such that, upon detonation of the perforatingdevices 210, a high-speed and high-pressure jet of liner particles andgas caused by detonation of the perforating devices 210 draws, propels,discharges, or otherwise forces the tracer material 432 out of theperforating tool 430 and into the perforation tunnels 113 formed by theperforating devices 210 in the formation 106. The tracer material 432may be inserted or otherwise disposed into the internal space 434 (suchas via an axial opening at an end of the support tube 224, as indicatedby arrow 436) before the support tube 224 is inserted into the outerhousing 226 or before the outer housing 226 is enclosed via connectionof the upper connector 230 with the outer housing 226.

The tracer material 432 may be or comprise tracer material particles(e.g., powder, pellets, etc.) held within one or more containers, whichmay be disposed axially within the internal space 434 between theperforating devices 210. The containers may be elongated or cylindrical,such that the containers may be inserted within the internal space 434between the perforating devices 210. The containers may be or comprise,for example, thin-walled paper, aluminum, rubber, polyurethane,polypropylene, polyethylene, and/or other metal or elastomeric materialsthat can be broken by the detonation of the perforating devices 210.

The tracer material 432 may instead be formed or otherwise shaped intoone or more solid units or members to facilitate placement within theinternal space 434. For example, the tracer material 432 may be formedor otherwise shaped into one or more cylindrical members or units topermit placement within the internal space 434 between the perforatingdevices 210. Each unit of tracer material 432 may be shaped bycompressing or pressing the tracer material particles within a moldhaving the intended shape of the tracer material 432. The tracermaterial 432 may also or instead be shaped by mixing tracer materialparticles with a fluid binder to form a tracer material slurry, whichmay be poured into a mold having the intended shape of the tracermaterial 432 and permitted to solidify. The tracer material 432 may alsoor instead be shaped by melting solid tracer material (e.g., tracermaterial particles), pouring the molten tracer material into a moldhaving the intended shape of the tracer material 432, and cooling moltentracer material within the mold.

FIG. 10 is a schematic side view of at least a portion of an exampleimplementation of a perforating tool 440 (i.e., a perforating gun)according to one or more aspects of the present disclosure. FIG. 11 is asectional axial view of the perforating tool 440 shown in FIG. 10. Theperforating tool 440 may be an example implementation of, and/orcomprise one or more features of, the perforating tool 200 describedabove and shown in FIG. 2, including where indicated by the samereference numerals. The following description refers to FIGS. 1, 2, 10,and 11, collectively.

The perforating tool 440 may contain tracer material 442 within aninternal space 444 of the support tube 224 adjacent the perforatingdevices 210 such that, upon detonation of the perforating devices 210, ahigh-speed and high-pressure jet of liner particles and gas caused bydetonation of the perforating devices 210 draws, propels, discharges, orotherwise forces the tracer material 442 out of the perforating tool 440and into the perforation tunnels 113 formed by the perforating devices210 in the formation 106. The tracer material 442 may be disposed withinthe internal space 444, such as via a plurality of radial openings in asidewall of the support tube 224, thereby permitting the tracer material442 to be inserted into the support tube 224 at a plurality of axiallocations along the support tube 224, as indicated by arrows 446. Thetracer material 442 may be inserted or otherwise disposed into theinternal space 444 before the support tube 224 is inserted into theouter housing 226.

The tracer material 442 may be or comprise tracer material particles(e.g., powder, pellets, etc.) held within a plurality of containers,which may be disposed within the internal space 444 between theperforating devices 210. The containers may be disk-shaped orcylindrical, such that the containers may be inserted within theinternal space 444 via the radial openings located between theperforating devices 210. The containers may be or comprise, for example,thin-walled paper, aluminum, rubber, polyurethane, polypropylene,polyethylene, and/or other metal or elastomeric materials that can bebroken by the detonation of the perforating devices 210.

The tracer material 442 may instead be formed or otherwise shaped into aplurality of solid units or members to facilitate placement within theinternal space 444. For example, the tracer material 442 may be formedor otherwise shaped into a plurality of disks, cylinders, or other flatunits to permit placement within the internal space 444 via the radialopenings located between the perforating devices 210. Each unit oftracer material 442 may be shaped by compressing or pressing tracermaterial particles (e.g., pellets, powder, etc.) within a mold havingthe intended shape of the tracer material 442. The tracer material 442may also or instead be shaped by mixing tracer material particles with afluid binder to form a tracer material slurry, which may be poured intoa mold having the intended shape of the tracer material 442 andpermitted to solidify. The tracer material 442 may also or instead beshaped by melting solid tracer material (e.g., tracer materialparticles), pouring the molten tracer material into a mold having theintended shape of the tracer material 442, and cooling molten tracermaterial within the mold.

The present disclosure is further directed to methods of deployingtracer material into a subterranean formation via a perforating tool(i.e., a perforating gun). FIGS. 12-14 are schematic sectional views ofa portion of the perforating tool 410 shown in FIGS. 4 and 5 comprisingthe perforating devices 300 shown in FIG. 3 during different stages oftracer deployment operations, during which the tracer material 412 isdeployed (e.g., moved, transferred, delivered, etc.) into theperforation tunnels 113 extending into the subterranean formation 106according to one or more aspects of the present disclosure. Thefollowing description refers to FIGS. 1-5 and 12-14, collectively.

Prior to conveying the perforating tool 410 downhole, the perforatingtool 410 may be assembled at the wellsite surface 104, includingdisposing tracer material 412 into the annular space 414 between thesupport tube 224 and the outer housing 226. The perforating tool 410,along with one or more other perforating tools 410, may then be coupledwithin or as part of the tool string 110. The tracer material 412associated with each perforating tool 410 of the tool string 110 may bedifferent or otherwise distinguishable (i.e., comprising differentdetectable signatures or characteristics) from the tracer material 412associated with other perforating tools 410 of the tool string 110. Thetool string 110 may then be conveyed within the wellbore 102 until anintended one of the perforating tools 410 is at an intended depth. Theperforating devices 300 of one or more of the perforating tools 410 maythen be operated (detonated) from the wellsite surface 104 or by thedownhole controller to perforate the well 102 and deploy the tracermaterial into the formation 106.

FIG. 12 shows a stage of tracer material deployment operations, shortlyafter the main explosive material 312 is detonated 350. A pressure wavegenerated by the exploding 350 main explosive material 312 folds orotherwise collapses the liner 314 within the hollow cavity 320, asindicated by arrows 358, and simultaneously propels the liner 314 alonga central axis of the perforating device 300. The pressure wave breaksup the liner 314 into liner particles 352, forming a high-pressure andhigh-speed jet of liner particles 352 and gas directed toward a sidewallof the wellbore 102, as indicated by arrow 360. Before impacting thesidewall of the wellbore 102, the jet of liner particles 352 may passthrough the tracer material 412 and penetrate the outer housing 226 ofthe perforating tool 410, forming a hole 361 therethrough.

FIG. 13 shows the jet of liner particles 352 perforating the casing 108,the cement 109, and the formation 106, thereby creating a perforationtunnel 113 extending into the formation 106. The exploding 350 explosivematerial 312 pressurizes the perforating tool 410, increasing pressurewithin the outer housing 226, the support tube 224, and other portionsof the perforating tool 410. The high-pressure and high-speed jet ofliner particles 352 and gas caused by the exploding 350 explosivematerial 312 breaks up the tracer material 412 (if shaped) into tracermaterial particles 356 and draws, propels, discharges, or otherwiseforces the tracer material particles 356 along and behind the linerparticles 352, out of the perforating tool 410, and then toward and intothe perforation tunnel 113, as indicated by arrows 362.

As shown in FIG. 14, the high-pressure gas formed by the exploding 350explosive material 312 that is trapped within the outer housing 226, thesupport tube 224, and other portions of the perforating tool 410continues to flow out of the perforating tool 410 via the hole 361, andinto the perforation tunnel 113, which is at a substantially lowerpressure. The high-pressure and high-speed flow of gas continues tobreak up the tracer material 412 into tracer material particles 356 anddischarge the tracer material particles 356 out of the perforating tool410 (via the hole 361) and into the perforation tunnel 113, as indicatedby arrows 364. The tracer material particles 356 may continue to flowinto the perforation tunnel 113 until all or substantially all of thetracer material 412 is discharged from the perforating tool 410, oruntil the gas pressure within the perforating tool 410 equalizes withthe pressure within the wellbore 102 and/or the perforation tunnel 113.

FIGS. 15-17 are schematic sectional views of a portion of theperforating tool 420 shown in FIGS. 6 and 7 comprising the perforatingdevices 300 shown in FIG. 3 during different stages of tracer deploymentoperations, during which the tracer material 422 is deployed into theperforation tunnels 113 extending into the subterranean formation 106according to one or more aspects of the present disclosure. Thefollowing description refers to FIGS. 1-3, 6, 7, and 15-17,collectively.

Prior to conveying the perforating tool 420 downhole, the perforatingtool 420 may be assembled at the wellsite surface 104, includingdisposing the tracer material 422 into the internal space 424 within thesupport tube 224. The perforating tool 420, along with one or more otherperforating tools 420, may then be coupled within or as part of the toolstring 110. The tracer material 422 associated with each perforatingtool 420 of the tool string 110 may be different or otherwisedistinguishable (i.e., comprising different detectable signatures orcharacteristics) from the tracer material 422 associated with otherperforating tools 420 of the tool string 110. The tool string 110 maythen be conveyed within the wellbore 102 until a predetermined one ofthe perforating tools 420 is at an intended depth. The perforatingdevices 300 of one or more of the perforating tools 420 may then beoperated (detonated) from the wellsite surface 104 or by the downholecontroller to perforate the well 102 and deploy the fluid tracers intothe formation 106.

FIG. 15 shows a stage of tracer material deployment operations, shortlyafter the main explosive material 312 is detonated 350. A pressure wavegenerated by the exploding 350 main explosive material 312 folds orotherwise collapses the liner 314 within the hollow cavity 320, asindicated by arrows 358, and simultaneously propels the liner 314 alonga central axis of the perforating device 300. The pressure wave breaksup the liner 314 into liner particles 352, forming a high-pressure andhigh-speed jet of liner particles 352 and gas directed toward a sidewallof the wellbore 102, as indicated by arrow 360. Before impacting thesidewall of the wellbore 102, the jet of liner particles 352 maypenetrate an outer housing 226 of the perforating tool 420, forming ahole 361 therethrough.

FIG. 16 shows the jet of liner particles 352 perforating the casing 108,the cement 109, and the formation 106, thereby creating a perforationtunnel 113 extending into the formation 106. The exploding 350 explosivematerial 312 pressurizes the perforating tool 420, increasing thepressure within the outer housing 226, the support tube 224, and otherportions of the perforating tool 420. The high-pressure and high-speedgas escaping the perforating tool 420 draws, propels, discharges, orotherwise forces the tracer material particles 356 along and behind theliner particles 352, out of the perforating tool 420, and then towardand into the perforation tunnel 113, as indicated by arrows 362. Thetracer material particles 356 may be discharged out of the support tube224 via a radial opening in the support tube 224 accommodating theperforating device 300. The pressure wave generated by the exploding 350main explosive material 312 and/or the high-pressure and high-speed gasescaping the support tube 224 may enlarge the radial opening in thesupport tube 224, thereby permitting the tracer material particles 356to be discharged out of the support tube 224, as indicated by the arrows362.

As shown in FIG. 17, the high-pressure gas formed by the exploding 350explosive material 312 that is trapped within the outer housing 226, thesupport tube 224, and other portions of the perforating tool 420continues to flow out of the perforating tool 420 (via the hole 361) andinto the perforation tunnel 113, which is at a substantially lowerpressure. The high-pressure and high-speed flow of gas continues todischarge the tracer material particles 356 out of the support tube 224and the perforating tool 420 via the hole 361 and into the perforationtunnel 113, as indicated by arrows 364. The tracer material particles356 may continue to flow into the perforation tunnel 113 until all orsubstantially all of the tracer material 422 is discharged from theperforation tool 420, or until the gas pressure within the perforatingtool 420 equalizes with the pressure within the wellbore 102 and/or theperforation tunnel 113.

Tracer deployment operations via the perforating tools 430, 440 shown inFIGS. 8-11 may be similar to the tracer deployment operations describedabove in association with the perforating tool 420 shown in FIG. 15-17.For example, during tracer deployment operations via the perforatingtools 430, 440, the exploding 350 explosive material 312 pressurizes theperforating tools 430, 440, increasing the pressure within the outerhousing 226, the support tube 224, and other portions of the perforatingtools 430, 440. Thereafter, high-pressure and high-speed flow of gasescaping from the perforating tools 430, 440 breaks up the tracermaterial 432, 442 (if shaped) and/or breaks the containers holdingparticulate tracer material 432, 442, and draws, propels, discharges, orotherwise forces the tracer material particles 356 out of the supporttube 224 and the perforating tool 430, 440 via the hole 361 and into theperforation tunnel 113.

FIG. 18 is a schematic view of at least a portion of an exampleimplementation of a perforating tool 500 (i.e., a perforating gun)according to one or more aspects of the present disclosure. Theperforating tool 500 may be an example implementation of, and/orcomprise one or more features of, the perforating tool 200 describedabove and shown in FIG. 2, including where indicated by the samereference numerals. The following description refers to FIGS. 1, 2, and18, collectively.

The perforating tool 500 comprises a plurality of perforating devices210, each comprising a liner 214, an explosive material 212 on one sideof the liner 214, and a case 215 on one side of the explosive material212. After the perforating tool 500 is conveyed to an intended depthwithin the wellbore 102, the explosive material 212 of each perforatingdevice 210 can be detonated to propel a corresponding liner 214 athigh-speed and high-pressure into a sidewall of the wellbore 102 toperforate or otherwise create a perforation tunnel 113 through thecasing 108 and the cement 109 and extending into the formation 106surrounding the wellbore 102. A batch (e.g., a predetermined weight orvolume, number of fluid tracer particles, etc.) of tracer material 502may be disposed in association with each perforating device 210, suchthat upon detonation of the explosive material 212, a high-speed jet ofliner particles and gas caused by the detonation breaks up and draws,propels, discharges, or otherwise forces the tracer material 502 along acorresponding perforation tunnel 113 into the formation 106. Each batchof the tracer material 502 may be disposed in front of the liner 214 ofa corresponding perforating device 210. Although the perforating tool500 is shown comprising sixteen perforating devices 210 (four columns ofperforating devices 210 distributed at 90 degrees apart) and thusoperable to create a cluster 111 of sixteen perforations 113, it is tobe understood that the perforating tool 500 can include other quantitiesof perforating devices 210.

Each explosive material 212 of the perforating devices 210 may bedetonated by a detonating cord 220 connected with or otherwise disposedin association with each perforating device 210 of the perforating tool500. An electric detonator 218 may be connected with the detonating cord220 and operable to detonate the detonating cord 218 to detonate theexplosive material 212 of each perforating device 210. The detonator 218may be connected to an electrical conductor 222, which may extend thoughthe perforating tool 500 between opposing upper and lower ends of theperforating tool 500. The conductor 222 may be or form a portion of theconductor 122 extending through the tool string 110 and the conveyanceline 120 to the surface equipment 130. The detonator 218 may also orinstead be communicatively connected with a detonator switch (e.g., anaddressable switch, a pressure switch, etc.) (not shown) located withina downhole tool 114 of the tool string 110. The detonator switch maypermit selective detonation, from the wellsite surface 104, of theperforating devices 210 of one or more perforating tools 500 coupledalong the tool string 110.

The perforating devices 210 may be held in relative position by asupport tube 224 (i.e., a charge tube). The perforating devices 210 maybe distributed longitudinally and circumferentially along the supporttube 224 and directed radially outward from the support tube 224. Eachperforating device 210 may be disposed partially or entirely within acorresponding cavity or opening extending radially within or through thesupport tube 224. Similarly, each batch of the tracer material 502 maybe disposed partially or entirely within a corresponding cavity oropening in the support tube 224. However, each batch of the tracermaterial 502 may be disposed outside or extend at least partially out ofthe corresponding cavity or opening in the support tube 222. Forexample, each batch of the tracer material 502 may extend radiallyoutward past an outer surface of the support tube 224. The support tube224 may be disposed within an outer housing 226 (i.e., carrier tube) ofthe perforating tool 500. The outer housing 226 may fluidly isolate eachperforating device 210 and corresponding tracer material 502 fromwellbore fluid when the perforating tool 500 is conveyed within thewellbore 102.

The perforating tool 500 may comprise an upper (i.e., uphole) connector230 operable to mechanically and electrically connect the perforatingtool 500 with an upper portion of the tool string 110, such as adownhole tool 114 or another perforating tool 500. The perforating tool500 may further comprise a lower (i.e., downhole) connector 232 operableto mechanically and electrically connect the perforating tool 500 with alower portion of the tool string 110, such as a plug setting tool 119 oranother perforating tool 500.

FIG. 19 is a schematic sectional view of at least a portion of anexample implementation of a perforating and tracer assembly 600comprising a perforating device 602 (i.e., a shaped charge, shapedexplosive, a perforating charge, etc.) and a tracer cap 604 comprisingtracer material 622 according to one or more aspects of the presentdisclosure. The perforating device 602 may comprise one or more featuresof the perforating device 300 described above and shown in FIG. 3,including where indicated by the same reference numerals. A plurality ofthe assemblies 600 or just the tracer caps 604 may be installed orotherwise utilized as part of or in association with a perforating tool,such as one or more of the perforating tools 116, 200, 410, 420, 430,440, 500 described above and show in FIGS. 1, 2, 4-11, and 18. Thefollowing description refers to FIGS. 1, 18, and 19, collectively.

The perforating device 602 may comprise a case 310 (i.e., a housing), amain explosive material 312 (i.e., a main explosive load, a secondaryexplosive) disposed within the case 310, and a liner 314 partiallysurrounded by the main explosive material 312. The liner 314 may have agenerally conical shape, having an outer surface in contact with themain explosive material 312 and an inner surface defining aconical-shaped hollow (e.g., air-filled) cavity 320 (i.e., a stand-offspace). The liner 314 may be or comprise metal, such as copper,aluminum, lead, and/or tin, among other examples. The liner 314 may beor comprise powdered metal, such as a metal matrix composite, shapedinto an intended form. The cavity 320 may define a front face of theperforating device 602. A primer explosive material 316 (i.e., primerload) may be disposed at the base (bottom) of the case 310 in contactwith the main explosive material 312 and adjacent an opening or hole 318through the case 310. A detonating cord 317 may extend along the case310 adjacent to or over the hole 318. The detonating cord 317 may beconnected to the case 310 via a guide or holder (not shown) integrallyformed with or otherwise connected with the case 310. Upon beingdetonated by the detonator 218, the detonating cord 317 may detonate theprimer explosive material 316, which, in turn, may detonate the mainexplosive material 312. The main explosive material 312 may be orcomprise, for example, RDX, HMX, or HNS, and a binding agent (i.e.,binder), such as wax or a polymer. The primer explosive material 316 maybe or comprise, for example, RDX, HMX, or HNS, but without a bindingagent. Although the main explosive material 312 of the perforatingdevice 602 may be detonated by the detonating cord 317 and the primerexplosive material 316, it is to be understood that the main explosivematerial 312 may be detonated by other means, such as an electricdetonator (i.e., a blasting cap) (not shown) disposed at the base of thecase 310 and electrically connected with the conductor 222 or adetonator switch.

The tracer cap 604 may contain or comprise a batch (e.g., apredetermined weight or volume, number of fluid tracer particles, etc.)of the tracer material 622 connected to or otherwise disposed inassociation with the perforating device 602. The tracer material 622 maybe formed or otherwise shaped to facilitate placement in associationwith the perforating device 602. For example, the tracer material 622may be formed or otherwise shaped to facilitate placement in front ofthe liner 314 of the perforating device 602 such that, upon detonationof the main explosive material 312, a high-speed and high-pressure jetof liner particles and gas breaks up and draws, propels, discharges, orotherwise forces the tracer material 622 into the formation 106. Thetracer material 622 may be shaped to define a hollow cavity 624 (i.e.,stand-off space). The hollow cavity 624 is disposed against the hollowcavity 320 of the liner 314 when the tracer material 622 is placed inassociation with the perforating device 602. An inner surface of thetracer material 622 may be conical and thus define a conical hollowcavity 624. The tracer material 622 may comprise a hole, bore, or otheropening 626 extending axially therethrough.

The tracer material 622 may be shaped by compressing or pressing tracermaterial particles (e.g., pellets, powder, etc.) within a mold havingthe intended shape of the tracer material 622. The tracer material 622may also or instead be shaped by mixing tracer material particles with afluid binder to form a tracer material slurry, which may be poured intoa mold having the intended shape of the tracer material 622 andpermitted to solidify. The tracer material 622 may also or instead beshaped by melting solid tracer material (e.g., tracer materialparticles), pouring the molten tracer material into a mold having theintended shape of the tracer material 622, and cooling molten tracermaterial within the mold. Each batch (i.e., shaped unit) of the tracermaterial 622 associated with a corresponding perforating device 602 maycomprise between about seven and about 25 grams of fluid tracers, ormore. For example, each shaped unit of tracer material 622 may compriseabout 7.0, 8.5, 10.0, 11.0, 12.0, 13.0, 13.5, 14.0, 15.0, 17.5, 20.0,22.5, or 25.0 grams of fluid tracers.

A case 630 (e.g., a cap, a cover, etc.) may contain, hold, accommodate,cover, and/or be disposed around each batch of the tracer material 622.The case 630 may be configured to connect with the case 310 of theperforating device 602, such as to maintain the tracer material 622positioned in front of the liner 314 and/or such that the hollowcavities 320, 624 are aligned. For example, an outer edge 632 of thecase 630 may be configured to extend over and/or around a portion of thecase 310 and connect with the case 310. The outer edge 632 may compriseinternal threads configured to engage external threads of the case 310.The outer edge 632 may also or instead comprise a flange 634 configuredto engage a corresponding flange 636 of the case 310. Fasteners 638,such as bolts, may be used to couple the corresponding flanges 634, 636.

The case 630 may be formed from or comprise a metal, a ceramic, apolymer, and/or other materials. The case 630 may be bowl-shaped, havinga convex outer surface and a concave inner surface. The inner surfacemay define a void or cavity for accommodating the tracer material 622therein. The case 630 may comprise semi-spherical outer and innersurfaces. The case 630 may comprise an opening 640 extending axiallytherethrough. The opening 640 may be axially aligned with the axialopening 626 of the tracer material 622. The tracer material 622 mayadhere to the case 630, such that the case 630 and the tracer material622 may be transported and/or connected with the perforating device 602as a single unit. For example, the tracer material 622 may be formedwithin the case 630, such as by pouring tracer material particles intothe case 630 and compressing the tracer material particles within thecase 630 via a press having an outer shape forming the cavity 624. Thecompression action may cause the tracer material 622 to be retainedwithin the case 630, such as via friction. The inner surface of the case630 may be coated with an adhesive, which may cause the tracer material622 to be retained within the case 630 when compressed within the case630. The tracer material 622 may also or instead be formed within thecase 630, such as by pouring molten tracer material or a tracer materialslurry into the case 630 and compressing the tracer material within thecase 630 via a press having an outer shape forming the cavity 624.However, the case 630 and the tracer material 622 may be or compriseseparate members, which may be assembled prior to or during connectionwith the perforating device 602.

FIGS. 20-29 are schematic sectional views of example implementations oftracer caps 701-710, respectively, that may be utilized in associationwith a perforating device, such as the perforating device 602 describedabove and shown in FIG. 19, instead of the tracer cap 604. The tracercaps 701-710 may comprise one or more features and modes of operation ofthe tracer cap 604. However, the tracer caps 701-710 may also or insteadcomprise features and modes of operation that are different from thoseof the tracer cap 604. Furthermore, although each tracer cap 604,701-710 comprises a specific combination of features, it is to beunderstood that other tracer caps comprising a different combination ofthe features shown in FIGS. 19-29 (among other possible features) arealso within the scope of the present disclosure. Accordingly, thefollowing description refers to FIGS. 19-29, collectively.

The tracer cap 701 comprises a case 711 and tracer material 712. Thecase 711 comprises semi-spherical inner and outer surfaces and an axialopening 713 extending between the inner and outer surfaces. The tracermaterial 712 comprises a conical hollow cavity 714 having a relativelyshort height 715, which does not extend to the opening 713, and arelatively small diameter (i.e., narrow) base 716 defining an opening ofthe cavity 714, which does not extend to an outer edge 717 of the case711. The tracer material 712 may comprise a relatively long bore 718extending between the cavity 714 and the opening 713.

The tracer cap 702 comprises a case 721 and tracer material 722. Thecase 721 comprises semi-spherical inner and outer surfaces and an axialopening 723 extending between the inner and outer surfaces. The tracermaterial 722 comprises a conical hollow cavity 724 having a relativelyshort height 725, which does not extend to the opening 723, and arelatively large diameter (i.e., wide) base 726 defining an opening ofthe cavity 724, which extends to an outer edge 727 of the case 721. Thetracer material 722 may comprise a relatively long bore 728 extendingbetween the cavity 724 and the opening 723.

The tracer cap 703 comprises a case 731 and tracer material 732. Thecase 731 comprises semi-spherical inner and outer surfaces and an axialopening 733 extending between the inner and outer surfaces. The tracermaterial 732 comprises a relatively small semi-spherical hollow cavity734 having a relatively small diameter 735 defining an opening of thecavity 734. The tracer material 732 comprises a relatively long bore 738extending between the cavity 734 and the opening 733.

The tracer cap 704 comprises a case 741 and tracer material 742. Thecase 741 comprises semi-spherical inner and outer surfaces and an axialopening 743 extending between the inner and outer surfaces. The tracermaterial 742 comprises a relatively large semi-spherical hollow cavity744 having a relatively large diameter 745 defining an opening of thecavity 744. The tracer material 742 comprises a relatively short bore748 extending between the cavity 744 and the opening 743.

The tracer cap 705 comprises a case 751 and tracer material 752. Thecase 751 comprises semi-spherical inner and outer surfaces and an axialopening 753 extending between the inner and outer surfaces. The tracermaterial 752 does not comprise a hollow cavity. The tracer material 752comprises a relatively long bore 758 that extends through the entiretracer material 752 and is aligned with the opening 753.

The tracer cap 706 comprises a case 761 and tracer material 762. Thecase 761 comprises conical inner and outer surfaces and an axial opening763 extending between the inner and outer surfaces. The tracer material762 comprises a conical hollow cavity 764 having a relatively shortheight 765, which does not extend to the opening 763, and a relativelysmall diameter (i.e., narrow) base 766 defining an opening of the cavity764, which does not extend to an outer edge 767 of the case 761. Thetracer material 762 may comprise a relatively long bore 768 extendingbetween the cavity 764 and the opening 763.

The tracer cap 707 comprises a case 771 and tracer material 772. Thecase 771 comprises oval (e.g., ellipsoidal) inner and outer surfaces andan axial opening 773 extending between the inner and outer surfaces. Thetracer material 772 comprises a conical hollow cavity 774 having arelatively short height 775, which does not extend to the opening 773,and a relatively small diameter (i.e., narrow) base 776 defining anopening of the cavity 774, which does not extend to an outer edge 777 ofthe case 771. The tracer material 772 may comprise a relatively longbore 778 extending between the cavity 774 and the opening 773.

The tracer cap 708 comprises a case 781 and tracer material 782. Thecase 781 comprises semi-spherical inner and outer surfaces and does notcomprise an axial opening. The tracer material 782 comprises arelatively small semi-spherical hollow cavity 784 having a relativelysmall diameter 785 defining an opening of the cavity 784. The tracermaterial 782 does not have a bore extending therethrough.

The tracer cap 709 comprises a case 791 and tracer material 792. Thecase 791 comprises semi-spherical inner and outer surfaces and does notcomprise an axial opening. The tracer material 792 comprises a conicalhollow cavity 793 having a relatively large height 794 extending to thecase 791, and a relatively large diameter (i.e., wide) base 795 definingan opening of the cavity 793 extending to an outer edge 796 of the case791. The tracer material 792 does not comprise a bore extendingtherethrough.

The tracer cap 710 comprises a case 797 and tracer material 798. Thecase 797 comprises semi-spherical inner and outer surfaces and does notcomprise an axial opening. The tracer material 732 does not comprise ahollow cavity nor a bore extending therethrough.

FIG. 30 is a schematic sectional view of an example implementation of aperforating device 790 (e.g., a shaped explosive charge, a perforatingcharge, etc.) according to one or more aspects of the presentdisclosure. The perforating device 790 may comprise one or more featuresand/or modes of operation of the perforating device 602 shown in FIG.19, including where indicated by the same reference numerals. Aplurality of the perforating devices 790 may be installed or otherwiseutilized as part of or in association with a perforating tool, such asone or more of the perforating tools 116, 200, 410, 420, 430, 440, 500described above and shown in FIGS. 1, 2, 4-11, and 18. The followingdescription refers to FIGS. 1, 19, and 30, collectively.

The perforating device 790 may comprise a case 310 (i.e., a housing), amain explosive material 312 disposed within the case 310, and a liner799 partially surrounded by the main explosive material 312. The liner799 may have a generally conical shape, having an outer surface incontact with or otherwise surrounded by the main explosive material 312and an inner surface defining a conical hollow (e.g., air-filled) cavity320 (i.e., a stand-off space). The cavity 320 may define a front face ofthe perforating device 790. A primer explosive material 316 may bedisposed at the base of the case 310 in contact with the main explosivematerial 312 and adjacent an opening or hole 318 through the case 310.The primer explosive material 316 may be detonated by a detonating cord317 or other means.

However, unlike the perforating device 602, the liner 799 of theperforating device 790 may be formed from or otherwise comprise tracermaterial. The tracer material liner 799 may be or comprise fluid tracersused to identify source of fluid. The tracer material liner 799 may beor comprise radioactive tracers, chemical tracers, and/or DNA tracers,among other examples. The tracer material liner 799 may comprise fluidtracers combined with particles of metal, such as one or more metalsused to form the liner 314.

The tracer material liner 799 may be shaped by compressing or pressing(e.g., hydraulically) tracer material particles (e.g., pellets, powder,etc.), metal particles, and/or binder material within a mold having theintended shape of the tracer material liner 799. The tracer materialliner 799 may also or instead be shaped by mixing tracer materialparticles, metal particles, and/or fluid binder material to form atracer material slurry, which may be poured into a mold having theintended shape of the tracer material liner 799 and permitted tosolidify. The tracer material liner 799 may also or instead be shaped bymelting mixed solid tracer material (e.g., tracer material particles),metal particles, and/or binder material, pouring the molten mix into amold having the intended shape of the tracer material liner 799, andcooling the molten mix within the mold.

If the perforating device 790 comprising the tracer material liner 799is used as part of a perforating gun, a tracer cap (e.g., the tracer cap604) and/or the tracer material 622 does not have to be disposed inassociation with the perforating device 790 (e.g., in front of the liner799). However, if an additional quantity of tracer material is intendedto be deployed into the formation 106, additional tracer material 622may be disposed in association with the perforating device 790 asdescribed herein and shown in FIGS. 19-29.

The present disclosure is further directed to methods of deployingtracer material into a subterranean formation via the perforating tool500 (i.e., a perforating gun). FIGS. 31-33 are schematic sectional viewsof a perforating and tracer assembly 600, shown in FIG. 19, of theperforating tool 500, shown in FIG. 18, during different stages oftracer deployment operations according to one or more aspects of thepresent disclosure. The perforating tool 500 comprises a plurality ofthe assemblies 600 collectively operable to form a plurality ofperforation tunnels 113 and deploy tracer material 622 into theformation 106 via the perforation tunnels 113. The following descriptionrefers to FIGS. 1, 18, 19, and 31-33, collectively.

Prior to conveying the perforating tool 500 downhole, the perforatingtool 500 may be assembled at the wellsite surface 104. The tracer caps604 and the perforating devices 602 may be connected together to formthe assemblies 600. If the individual batches of the tracer material 622are separate from the cases 630, the batches of the tracer material 622may first be inserted into the corresponding cases 630 and then thecases 630 may be connected with the perforating devices 602 to maintaineach batch of the tracer material 622 in front of a corresponding liner314 of the perforating device 602. The assemblies 600 may then beindividually installed within the support tube 224 of the perforatingtool 500 and connected with the detonating cord 220. However, theperforating devices 602 may instead be individually installed within thesupport tube 224 first. After the perforating devices 602 are installed,the tracer caps 604, each comprising the tracer material 622 disposedwithin the case 630, may be connected with the perforating devices 602.The support tube 224 with the assemblies 600 may then be inserted intothe outer housing 226. The tracer material 622 associated with one ormore of the assemblies 600 within the perforating tool 500 may bedifferent or otherwise distinguishable (i.e., comprising differentdetectable signatures or characteristics) from the tracer material 622associated with one or more other assemblies 600 and within the sameperforating tool 500. The perforating tool 500, along with one or moreother perforating tools 500, may then be coupled within or as part of atool string 110. The tracer material 622 associated with eachperforating tool 500 of the tool string 110 may be different orotherwise distinguishable from the tracer material 622 associated withother perforating tools 500 of the tool string 110. The tool string 110may then be conveyed within a wellbore 102 until an intended one of theperforating tools 500 is at an intended depth. The perforating devices602 of one or more intended perforating tools 500 may then be operated(detonated) from the wellsite surface 104 or by the downhole controllerto perforate the well 102 and deploy the tracer material 622 into theformation 106.

FIG. 31 shows a stage of tracer material deployment operations, shortlyafter the main explosive material is detonated 350. A pressure wavegenerated by the exploding 350 main explosive material folds orotherwise collapses the liner within the hollow cavity 320, as indicatedby arrows 358, and simultaneously propels the liner along a central axisof the perforating device 602. The pressure wave breaks up the linerinto liner particles 352, forming a high-pressure and high-speed jet ofliner particles 352 and gas directed toward a sidewall of the wellbore102, as indicated by arrow 360. Before impacting the sidewall of thewellbore 102, the jet of liner particles 352 exits the perforating tool500 comprising the assembly 600 by penetrating an outer housing 226 ofthe perforating tool 500.

FIG. 32 shows the jet of liner particles 352 perforating the casing 108,the cement 109, and the formation 106, thereby creating a perforationtunnel 113 through the casing 108 and the cement 109 and into theformation 106. The high-pressure and high-speed jet of liner particles352 and gas caused by the exploding 350 explosive material breaks up thetracer material 622 (and the case 630) into tracer material particles356 and draws, propels, discharges, or otherwise forces the tracermaterial particles 356 along and behind the liner particles 352, out ofthe perforating tool 500, and then toward and into the perforationtunnel 113, as indicated by arrows 362.

As shown in FIG. 33, high-pressure gas within the hollow cavity 320caused by the exploding 350 explosive material continues to flow out ofthe hollow cavity 320 and the perforating tool 500 and into theperforation tunnel 113, which is at a substantially lower pressure. Thehigh-pressure and high-speed flow of gas continues to break up thetracer material 622 into tracer material particles 356 and dischargesthe liner particles 352 into the perforation tunnel 113, as indicated byarrows 364. The tracer material particles 356 may continue to flow intothe perforation tunnel 113 until all or substantially all of the tracermaterial 622 is broken up and discharged from the tracer cap 604, oruntil the gas pressure within the hollow cavity 320 and/or the outerhousing 226 equalizes with pressure within the wellbore 102 and/or theperforation tunnel 113.

A perforating tool, such as one of the perforating tools 116, 200, 500shown in FIGS. 1, 2, and 18, respectively, comprising a plurality of theperforating devices 790 shown in FIG. 30 may also or instead be utilizedto deliver or deploy fluid tracers into the formation 106. Suchdeployment operations may be similar to those described above and shownin FIGS. 31 and 32. The following description refers to FIGS. 1, 2, 18,and 30-32.

Prior to conveying the perforating tool downhole, the perforating toolmay be assembled at the wellsite surface 104. The perforating devices790, with or without tracer caps 604 shown in FIG. 19, may beindividually installed within a support tube 224 of the perforating tooland connected with a detonating cord 220. The support tube 224 with theperforating devices 790 may then be inserted into an outer housing 226.The tracer material of the liner 799 associated with one or more of theperforating devices 790 within the perforating tool may be different orotherwise distinguishable (i.e., comprising different detectablesignatures or characteristics) from the tracer material of the liner 799associated with one or more other perforating devices 790 within thesame perforating tool. The perforating tool, along with one or moreother perforating tools, may then be coupled within or as part of a toolstring 110. The tool string 110 may then be conveyed within a wellbore102 until the perforating tool is at an intended depth. The perforatingdevices 790 of one or more intended perforating tools may then beoperated (detonated) from the wellsite surface 104 or by the downholecontroller to perforate the well 102 and deploy the tracer material intothe formation 106.

Although FIGS. 31 and 32 show deployment of the tracer material 622located within a tracer cap 604, deployment operations of the tracermaterial located within the liner 799 may be similar to those shown inFIGS. 31 and 32. Assuming that arrangement shown in FIGS. 31 and 32utilize the perforating device 790 shown in FIG. 30 in place of theperforating device 602, the exploding 350 explosive material folds orotherwise collapses the fluid tracer liner 799 within the hollow cavity320, as indicated by arrows 358, and simultaneously propels the liner799 along a central axis of the perforating device 790. The pressurewave breaks up the liner 799 into liner particles 352, forming ahigh-pressure and high-speed jet of fluid tracer liner particles 352 andgas directed toward a sidewall of the wellbore 102, as indicated byarrow 360. The jet of fluid tracer liner particles 352 then penetratesthe casing 108, the cement 109, and the formation 106 to create theperforation tunnel 113. The fluid tracer liner particles 352 continue topenetrate the formation 106, forming the perforation tunnel 113, whilethe kinetic energy of the fluid tracer liner particles 352 decrease.When the fluid tracer liner particles 352 stop, the fluid tracer linerparticles 352 are embedded and thus deployed within the formation 106.If additional tracer material is intended to be deployed, a tracer cap604 containing tracer material 622 may be disposed in association withthe perforating device 790, which may be operated to deploy the tracermaterial 622 within the formation 106, as described above and shown inFIGS. 31-33.

The present disclosure is further directed to methods of testing ormonitoring the formation fluid produced from the formation for thetracer material (i.e., fluid tracers) to identify contributions (e.g.,percentages) of the formation fluids produced from each cluster 111 ofperforation tunnels 113, each fracturing stage interval 103, 105, 107,and/or from other predetermined portions or intervals of the formation106. FIG. 34 is a schematic sectional view of a perforating tool 800(e.g., one of the perforating tools 116, 200, 410, 420, 430, 440, 500)comprising a perforating device 802 (e.g., one of the perforatingdevices 117, 210, 300, 600, 790) that was conveyed within a wellbore 102to an intended depth and operated to form a perforation tunnel 113 anddeploy tracer material 804 in a formation 106, such as via the actionsdescribed above and shown in FIGS. 12-17 and 31-33. The perforationtunnel 113 formed by the perforating device 802 extends through thecasing 108 and cement 109 and into the formation 106 within a fracturingstage interval 105. Tracer material particles 804 are deployed withinthe perforation tunnel 113 and/or within a crushed formation region 806surrounding the perforation tunnel 113. The perforating device 802 isone of a plurality of perforating devices 802 and, thus, the perforationtunnel 113 is one of a plurality (e.g., a cluster 111) of perforationtunnels 113 that may be formed in the formation 106 within thefracturing stage interval 105 via one or more perforating tools 800 andinto which the tracer material 804 may be deployed via the actionsdescribed above. As shown in FIG. 1, a plurality of perforation tunnelclusters 111 may be formed in the formation 106 within the fracturingstage interval 105. Tracer material 804 having different or otherwisedifferentiable signatures (e.g., indicators, characteristics, markers,etc.) may be deployed within each cluster 111 of perforation tunnels 113within the same fracturing stage interval (e.g., the fracturing stageinterval 105). However, tracer material 804 having the same signaturesmay be deployed within each cluster 111 of perforation tunnels 113within the same the same fracturing stage interval. Thus, the detectablesignature of the tracer material 804 deployed within each perforationtunnel 113 of a cluster 111 may be the same, but different from thedetectable signature of tracer material 804 deployed within theperforation tunnels 113 of another cluster 111 within the same ordifferent fracturing stage interval.

FIG. 35 is a schematic sectional view of the formation 106 within thefracturing stage interval 105 containing the perforation tunnel 113shown in FIG. 34 during subsequent fracturing operations. Duringfracturing operations, fracturing fluid 814 may be pumped downhole alongthe wellbore 102, thus forcing the fracturing fluid 814 into theperforation tunnel 113 (and other perforation tunnels 113 of the samecluster and of other clusters 111 within the fracturing stage interval105) and pushing the tracer material particles 804 along the perforationtunnel 113. While the pressure of the fracturing fluid 814 increases,fractures 808 extending from the perforation tunnel 113 along theformation 106 within the fracturing stage interval 105 are formed. Thefracturing fluid 814 further carries suspended tracer material particles804 into and along the fractures 808, further disseminating or spreadingthe tracer material particles 804 within the formation 106, as indicatedby the arrows 810.

FIG. 36 is a schematic sectional view of the formation 106 containingthe perforation tunnel 113 and the fractures 808 shown in FIG. 35 duringsubsequent flow-back and/or hydrocarbon production operations(collectively “uphole flow operations”). During uphole flow operations,formation fluid 812 (e.g., hydrocarbons) is expelled from the formation106 within the fracturing stage interval 105 (and perhaps from otherfracturing stage intervals 103, 107) and transmitted via the fractures808 and the perforation tunnel 113 while carrying suspended tracermaterial particles 804 therewith. The formation fluid 812 with thetracer material particles 804 is then transmitted into the wellbore 102via the perforation tunnel 113 (and other perforation tunnels 113), asindicated by arrows 816, and to the wellsite surface 104 via thewellbore 102. The formation fluid 812 may be analyzed at the wellsitesurface 104 to determine relative concentrations or amounts of eachdistinguishable tracer material (i.e., tracer material particles 804)reaching the wellsite surface 104 to determine or identify thecontribution (e.g., relative amount or percentage) of the formationfluid 812 produced from each cluster 111 of perforation tunnels 113and/or from each fracturing stage interval 103, 105, 107 with respect tothe total formation fluid produced from the wellbore 102.

Differentiable tracer material 804 may be deployed within each cluster111 of perforation tunnels 113 within the same fracturing stage interval103, 105, 107. Thus, after a cluster 111 of perforation tunnels 113 areformed within a selected fracturing stage interval (e.g., the fracturingstage interval 105) and distinguishable tracer material particles 804are deployed therein, the tool string 110 containing the perforatingtools 800 may be conveyed uphole (or downhole) to other intendeddepth(s) within the same fracturing stage interval 105. Perforatingdevices 802 of one or more other perforating tools 800 may then beoperated to form another cluster 111 of perforation tunnels 113 anddeploy other distinguishable tracer material particles 804 therein. Thetracer material 804 deployed into each cluster 111 of perforationtunnels 113 within the same fracturing stage interval 105 may bedistinguishably different, thereby permitting monitoring of fluid flowcontribution of each cluster 111 of perforation tunnels 113 (andcorresponding fractures 808) and, thus, monitoring of perforation and/orfracturing efficiency of each cluster 111 of perforation tunnels 113(and corresponding fractures 808) within the same fracturing stageinterval 105.

However, the tracer material 804 deployed into each cluster 111 ofperforation tunnels 113 within a selected fracturing stage interval(e.g., the fracturing stage interval 105) may be indistinguishable, butdistinguishable from tracer material 804 deployed into each cluster 111of perforation tunnels 113 within another fracturing stage interval(e.g., the fracturing stage intervals 103, 107), thereby permittingmonitoring of fluid flow contribution of each fracturing stage interval103, 105, 107 and thus monitoring of perforation and/or fracturingefficiency of each fracturing stage interval 103, 105, 107, as a whole.Thus, before each stage of fracturing operations, a tool string 110 maybe conveyed downhole to isolate a previous fracturing stage interval andto form perforation tunnels 113 within a subsequent fracturing stageinterval and deploy the tracer material 804 therein. For each suchconveyance and downhole operations, the tool string 110 may include aperforating tool 800 comprising a different distinguishable tracermaterial 804 for deployment into the perforation tunnels 113.

In view of the entirety of the present disclosure, including the figuresand the claims, a person having ordinary skill in the art will readilyrecognize that the present disclosure introduces an apparatus comprisingtracer material shaped to facilitate placement in association with aperforating gun, wherein detonation of shaped charges of the perforatinggun forms perforation tunnels in a subterranean formation and dischargesthe tracer material from the perforating gun into the perforationtunnels.

The tracer material may be shaped to facilitate placement within theperforating gun.

The tracer material may be shaped to facilitate placement between anouter housing of the perforating gun and an inner tube supporting theshaped charges.

The tracer material may be shaped to facilitate placement within ashaped charge support tube of the perforating gun.

The tracer material may be shaped to facilitate placement in associationwith each of the shaped charges.

The tracer material may be shaped to facilitate placement in front ofeach of the shaped charges.

The tracer material may be or comprise distinguishable fluid tracersconfigured to be carried by formation fluid and used to identify asource of the formation fluid.

The tracer material may be or comprise at least one of radioactivetracers, chemical tracers, and DNA tracers.

The present disclosure also introduces an apparatus comprising a linerfor use as part of a shaped charge for a perforating gun, wherein theliner comprises tracer material.

The liner may have a substantially conical shape.

Detonation of the shaped charge may propel the liner to form aperforation tunnel in a subterranean formation thereby deploying thetracer material into the perforation tunnel.

The liner may further comprise a metal.

The liner may comprise a mixture of particles of the tracer material andparticles of a metal held together in a predetermined shape.

The tracer material may be or comprise distinguishable fluid tracersconfigured to be carried by formation fluid and used to identify asource of the formation fluid.

The tracer material may be or comprise at least one of radioactivetracers, chemical tracers, and DNA tracers.

The present disclosure also introduces an apparatus comprising tracermaterial shaped to facilitate placement in front of a shaped charge of aperforating gun, wherein detonation of the shaped charge forms aperforation tunnel in a subterranean formation and discharges the tracermaterial from the perforating gun into the perforation tunnel.

The tracer material may be shaped to comprise a hollow cavity. Thehollow cavity of the tracer material may be disposed against a hollowcavity of a liner of the shaped charge when the tracer material isplaced in front of the shaped charge. The hollow cavity of the tracermaterial may have a substantially semi-spherical shape or asubstantially conical shape.

The tracer material may be shaped to comprise a hole extending axiallytherethrough.

The apparatus may further comprise a case disposed around the tracermaterial. The case may be configured for connection with the shapedcharge. The case may have a substantially semi-spherical shape. The casemay be or comprise a metal. The tracer material may adhere to the case.

The tracer material may be or comprise distinguishable fluid tracersconfigured to be carried by formation fluid and used to identify asource of the formation fluid.

The tracer material may be or comprise at least one of radioactivetracers, chemical tracers, and DNA tracers.

The present disclosure also introduces an apparatus comprising aperforating gun comprising a plurality of shaped charges and containingtracer material, wherein detonation of the shaped charges: formsperforation tunnels in the subterranean formation; and discharges thetracer material from the perforating gun into the perforation tunnels.

The tracer material may be disposed between an outer housing of theperforating gun and an inner tube supporting the shaped charges.

The tracer material may be disposed within a shaped charge support tubeof the perforating gun.

The tracer material may be disposed in association with each of theshaped charges. The tracer material may be disposed in front of each ofthe shaped charges.

The tracer material may be or comprise distinguishable fluid tracersconfigured to be carried by formation fluid and used to identify asource of the formation fluid.

The tracer material may be or comprise at least one of radioactivetracers, chemical tracers, and DNA tracers.

The present disclosure also introduces a method comprising deployingtracer material into a subterranean formation via a perforating gun.

Deploying the tracer material into the subterranean formation via theperforating gun may comprise deploying the tracer material into thesubterranean formation via shaped charges of the perforating gun.

Deploying the tracer material into the subterranean formation via theperforating gun may comprise detonating shaped charges of theperforating gun to: form perforation tunnels in the subterraneanformation; and discharge the tracer material from the perforating guninto the perforation tunnels.

The method may further comprise, before deploying the tracer materialinto the subterranean formation via the perforating gun, installing thetracer material as part of the perforating gun.

The tracer material may be or comprise distinguishable fluid tracersconfigured to be carried by formation fluid and used to identify asource of the formation fluid.

The tracer material may be or comprise at least one of radioactivetracers, chemical tracers, and DNA tracers.

The tracer material may be a first tracer material, the perforating gunmay be a first perforating gun, the method may further comprisedeploying second tracer material into the subterranean formation via asecond perforating gun, the first tracer materials and the second tracermaterial may be distinguishable, and the first perforating gun and thesecond perforating gun may be part of the same downhole tool string.

The tracer material may be a first tracer material, the perforating gunmay be a first perforating gun, and deploying the first tracer materialinto the subterranean formation via the first perforating gun maycomprise: conveying to a first wellbore depth a tool string comprisingthe first perforating gun containing the first tracer material; andoperating the first perforating gun to detonate first shaped charges ofthe first perforating gun thereby forming a first set of perforatingtunnels in the subterranean formation and forcing the first tracermaterial into the first set of perforating tunnels. The method mayfurther comprise: conveying to a second wellbore depth the tool stringcomprising a second perforating gun containing second tracer material;and operating the second perforating gun to detonate second shapedcharges of the second perforating gun thereby forming a second set ofperforating tunnels in the subterranean formation and forcing the secondtracer material into the second set of perforating tunnels, wherein thefirst tracer material and the second tracer material aredistinguishable. The method may further comprise: fracturing thesubterranean formation via the first and second sets of perforationtunnels; producing formation fluid from the fractured subterraneanformation to the wellsite surface; and analyzing the formation fluid atthe wellsite surface to determine relative amounts of the first andsecond tracer material in the formation fluid to determine relativeamount of the formation fluid produced via each of the first and secondsets of perforation tunnels.

The foregoing outlines features of several embodiments so that a personhaving ordinary skill in the art may better understand the aspects ofthe present disclosure. A person having ordinary skill in the art shouldappreciate that they may readily use the present disclosure as a basisfor designing or modifying other processes and structures for carryingout the same purposes and/or achieving the same advantages of theembodiments introduced herein. A person having ordinary skill in the artshould also realize that such equivalent constructions do not departfrom the scope of the present disclosure, and that they may make variouschanges, substitutions and alterations herein without departing from thescope of the present disclosure.

What is claimed is:
 1. An apparatus comprising: tracer material shapedto facilitate placement in association with a perforating gun, whereindetonation of shaped charges of the perforating gun forms perforationtunnels in a subterranean formation and discharges the tracer materialfrom the perforating gun into the perforation tunnels.
 2. The apparatusof claim 1 wherein the tracer material is shaped to facilitate placementwithin the perforating gun.
 3. The apparatus of claim 1 wherein thetracer material is shaped to facilitate placement in association witheach of the shaped charges.
 4. The apparatus of claim 1 wherein thetracer material is shaped to facilitate placement in front of each ofthe shaped charges.
 5. The apparatus of claim 1 wherein the tracermaterial is or comprises distinguishable fluid tracers configured to becarried by formation fluid and used to identify a source of theformation fluid.
 6. The apparatus of claim 1 wherein the tracer materialis or comprises at least one of: radioactive tracers; chemical tracers;and DNA tracers.
 7. An apparatus comprising: a perforating guncomprising a plurality of shaped charges and containing tracer material,wherein detonation of the shaped charges: forms perforation tunnels inthe subterranean formation; and discharges the tracer material from theperforating gun into the perforation tunnels.
 8. The apparatus of claim7 wherein the tracer material is disposed within an outer housing of theperforating gun.
 9. The apparatus of claim 7 wherein the tracer materialis disposed in association with each of the shaped charges.
 10. Theapparatus of claim 7 wherein the tracer material is or comprisesdistinguishable fluid tracers configured to be carried by formationfluid and used to identify a source of the formation fluid.
 11. Theapparatus of claim 7 wherein the tracer material is or comprises atleast one of: radioactive tracers; chemical tracers; and DNA tracers.12. A method comprising: deploying tracer material into a subterraneanformation via a perforating gun.
 13. The method of claim 12 whereindeploying the tracer material into the subterranean formation via theperforating gun comprises deploying the tracer material into thesubterranean formation via shaped charges of the perforating gun. 14.The method of claim 12 wherein deploying the tracer material into thesubterranean formation via the perforating gun comprises detonatingshaped charges of the perforating gun to: form perforation tunnels inthe subterranean formation; and discharge the tracer material from theperforating gun into the perforation tunnels.
 15. The method of claim 12further comprising, before deploying the tracer material into thesubterranean formation via the perforating gun, installing the tracermaterial as part of the perforating gun.
 16. The method of claim 12wherein the tracer material is or comprises distinguishable fluidtracers configured to be carried by formation fluid and used to identifya source of the formation fluid.
 17. The method of claim 12 wherein thetracer material is or comprises at least one of: radioactive tracers;chemical tracers; and DNA tracers.
 18. The method of claim 12 wherein:the tracer material is a first tracer material; the perforating gun is afirst perforating gun; the method further comprises deploying secondtracer material into the subterranean formation via a second perforatinggun; the first tracer materials and the second tracer material aredistinguishable; and the first perforating gun and the secondperforating gun are part of the same downhole tool string.
 19. Themethod of claim 12 wherein: the tracer material is a first tracermaterial; the perforating gun is a first perforating gun; deploying thefirst tracer material into the subterranean formation via the firstperforating gun comprises: conveying to a first wellbore depth a toolstring comprising the first perforating gun containing the first tracermaterial; and operating the first perforating gun to detonate firstshaped charges of the first perforating gun thereby forming a first setof perforating tunnels in the subterranean formation and forcing thefirst tracer material into the first set of perforating tunnels; themethod further comprises: conveying to a second wellbore depth the toolstring comprising a second perforating gun containing second tracermaterial; and operating the second perforating gun to detonate secondshaped charges of the second perforating gun thereby forming a secondset of perforating tunnels in the subterranean formation and forcing thesecond tracer material into the second set of perforating tunnels,wherein the first tracer material and the second tracer material aredistinguishable.
 20. The method of claim 19 further comprising:fracturing the subterranean formation via the first and second sets ofperforation tunnels; producing formation fluid from the fracturedsubterranean formation to the wellsite surface; and analyzing theformation fluid at the wellsite surface to determine relative amounts ofthe first and second tracer material in the formation fluid to determinerelative amount of the formation fluid produced via each of the firstand second sets of perforation tunnels.